Chemical deepwater stimulation systems and methods

ABSTRACT

Systems and methods for performing operations on a well include first and second flow control devices positioned between upper and lower sections of a conduit. An upper connector assembly engaged with the upper section includes connectors adapted for connection to a chemical stimulation device, a blowout preventer, or other well intervention apparatuses. A lower connector assembly engaged with the lower section includes connectors adapted for connection to a chemical stimulation device, a running tool, wellbore conduits, or other well intervention apparatuses. The two connector assemblies, above and below the flow control devices, enable sequential or simultaneous operations to be performed, and can enable operations to be performed independent of the state of the flow control devices.

FIELD

Embodiments usable within the scope of the present disclosure relate, generally, to systems and methods usable to perform chemical (e.g., acid) stimulation operations on a wellbore, in combination with other well intervention operations, while minimizing or eliminating the downtime normally required to remove, reposition, and/or replace equipment.

BACKGROUND

Acid stimulation is frequently used as a form of well intervention to restore production of a well to peak levels. Conventional methods for acid stimulation require use of large rigs and risers, while alternative systems can use remotely operable vehicles (ROVs), multi-service vessels (MSVs), or similar devices to access a wellhead in deep water, e.g., using coiled tubing ballasted with weight to ensure proper descent and stabilization over a working area. A significant length of conduit (e.g., 150 feet) is often necessary to ensure that the flying leads and connectors of the tubing can accommodate vessel heave and position deviation while allowing ample room for the front panel on the injection tool at the wellhead to be accessed.

When a well stimulation and/or an injection tool is engaged with a subsea well tree, other intervention operations are inhibited and/or rendered impossible, resulting in a significant downtime between well simulation and other intervention operations and necessitating the replacement and use of various equipment.

Conventional methods allow for acid injection via subsea umbilical/flying leads, e.g., through the installation of an acid tool that latches onto a tree via a tree running tool. Such methods allow for injection, but do not allow the wellbore to be accessed and/or only enable access via steel tubing and/or hosing. Thus, items having large outer diameters, such as an internal tree plug or wireline tools, cannot enter the wellbore. Essentially, wireline equipment cannot be operated within an umbilical or similar conduit due to the inherent physical constraints of the umbilical.

The limitation of equipment and methods that only permit injection of acid without having the ability to enter the well using wireline equipment contributes to operational downtime, as a separate pressure control assembly (e.g., a blowout preventer) is then needed to access the well with wireline equipment.

A need exists for systems and methods that enable both well stimulation operations and other intervention operations to be conducted, while minimizing the replacement of equipment and downtime therebetween, while maintaining at least two barrier valves to isolate the wellbore.

A further need exists for systems and methods that enable running of wireline equipment while providing at least two isolation barriers, the two or more barriers being closable to allow chemical injection to take place via placement of isolation barriers in an exterior portion (e.g., “wings”) of the system.

A need also exists for systems and methods that can be operated riglessly, or alternatively using only a small hoist and/or a multi-service vessel, eliminating the need for conventional rig and riser-based installation procedures. A lubricator and/or a “greasehead” can be used to create a seal during such rigless wireline operations.

SUMMARY

Embodiments usable within the scope of the present disclosure relate to systems usable for performing operations on a well that include a conduit (e.g., a central conduit in communication with a wellbore) having an upper section and a lower section. A first flow control device, such as a barrier valve or other similar types of valves (e.g., ball valves or hydraulic valves), regulators, and/or devices usable to limit, divert, or prevent the flow of fluid, can be positioned between the upper and lower sections of the conduit. Similarly, a second flow control device can be positioned beneath (e.g., in a downhole direction) the first flow control device, between the upper and lower sections of the conduit, thereby forming a double-barrier usable to isolate the wellbore.

An upper connector assembly can be engaged with the upper section of the conduit for enabling communication therewith. The upper connector assembly can include a first flow cross member in fluid communication with the first flow control device, the first flow cross member enabling fluid flow in at least two directions. The upper connector assembly can further include a connector adapted for connection to a chemical stimulation device (e.g., an acid stimulation unit) or a similar well intervention apparatus, and a top connector, usable for engagement with a blowout preventer, and/or for performing chemical stimulation or other well intervention operations therethrough.

Similarly, a lower connector assembly can be engaged with the lower section of the conduit and includes a second flow cross member in fluid communication with the second flow control device, the second flow cross member enabling fluid flow in at least two directions. The lower connector assembly can include a connector adapted for connection to a chemical stimulation device or a similar well intervention apparatus, and a bottom connector adapted for engaging a running tool, a wellbore conduit, a blowout preventer, or combinations thereof.

Pump in lines can be engaged with the connectors of either or both of the upper and lower connector assemblies, to be used for chemical stimulation, connection to a tree running tool, or other intervention operations, without requiring installation of additional equipment. Thus, the upper connector assembly can be used to perform stimulation and/or other intervention operations through a pump in line and/or the top connector, through the first and second flow control devices (e.g., when the flow control devices are open to permit fluid flow and/or passage of other materials), and/or to accommodate a blowout preventer, while the lower connector assembly can be used to perform stimulation and/or other well operations independent of the first and second flow control devices (e.g., even when the barrier valves or similar flow control devices are closed). Thus, for example, the bottom section of the system could be used for well stimulation while the top section is used for other well operations, simultaneously or in combination therewith. The connectors of either or both of the upper and lower connector assemblies can include emergency quick disconnect (EQD) members to enable rapid disconnection when necessary to close the system and ensure safe operation and/or departure of any vessel.

BRIEF DESCRIPTION OF THE DRAWINGS

In the detailed description of various embodiments usable within the scope of the present disclosure, presented below, reference is made to the accompanying drawings, in which:

FIG. 1 depicts a diagrammatic side view of an embodiment of a system usable within the scope of the present disclosure.

FIG. 2 depicts a diagrammatic side view of an alternate embodiment of a system usable within the scope of the present disclosure.

FIG. 3 depicts a diagrammatic side view of another embodiment of a system usable within the scope of the present disclosure.

FIG. 4 depicts a diagrammatic side view of an additional embodiment of a system usable within the scope of the present disclosure.

One or more embodiments are described below with reference to the listed Figures.

DETAILED DESCRIPTION OF THE EMBODIMENTS

Before describing selected embodiments of the present disclosure in detail, it is to be understood that the present invention is not limited to the particular embodiments described herein. The disclosure and description herein is illustrative and explanatory of one or more presently preferred embodiments and variations thereof, and it will be appreciated by those skilled in the art that various changes in the design, organization, order of operation, means of operation, equipment structures and location, methodology, and use of mechanical equivalents may be made without departing from the spirit of the invention.

As well, it should be understood that the drawings are intended to illustrate and plainly disclose presently preferred embodiments to one of skill in the art, but are not intended to be manufacturing level drawings or renditions of final products and may include simplified conceptual views as desired for easier and quicker understanding or explanation. As well, the relative size and arrangement of the components may differ from that shown and still operate within the spirit of the invention.

Moreover, it will be understood that various directions such as “upper,” “lower,” “bottom,” “top,” “left,” “right,” and so forth are made only with respect to explanation in conjunction with the drawings, and that the components may be oriented differently, for instance, during transportation and manufacturing as well as operation. Because many varying and different embodiments may be made within the scope of the concepts herein taught, and because many modifications may be made in the embodiments described herein, it is to be understood that the details herein are to be interpreted as illustrative and non-limiting.

Embodiments usable within the scope of the present disclosure relate to systems and methods usable to perform wellbore intervention operations (e.g., chemical stimulation, tubular running, and/or other similar operations) without requiring removal, repositioning, and/or replacement of existing equipment to perform different operations, and in an embodiment, without requiring use of a rig or similar maneuvering equipment.

Conventional methods for performing chemical stimulation operations require use of a large rig to hoist risers into place and run these risers from a large vessel to the wellbore. After a chemical stimulation operation is performed, the required equipment must be removed and replaced with other equipment for performing additional intervention operations. Embodiments usable within the scope of the present disclosure overcome these and other limitations of existing systems and methods.

Referring now to FIG. 1, a diagrammatic side view of an embodiment of a system (10) usable within the scope of the present disclosure is shown. The system (10) includes a central conduit (12) positioned above a wellbore (e.g., in an uphole direction relative to the wellbore), an additional conduit communicating with a wellbore, and/or a running tool (not shown). The central conduit (12) includes an upper section (14) and a lower section (16). It should be noted that the division of the conduit (12) into upper and lower sections (14, 16) is a conceptual division to facilitate clarity, and does not necessarily require that the conduit (12) include multiple separable members, as depicted. Embodiments usable within the scope of the present disclosure can include integral and/or unitary conduits, or conduits having any number of physical components.

As shown, a first flow control device (18) and a second flow control device (20), which can include ball valves, hydraulic valves, and/or other similar devices usable to restrict, regulate, prevent, and/or divert fluid flow, are positioned between the upper and lower sections (14, 16) of the conduit (12), enabling isolation of the upper section (14) from the lower section (16), and enabling isolation of the wellbore from the upper section (14) and/or the environment external to the conduit (12).

The upper section (14) is shown having an upper connector assembly that includes a first flow cross member (22) (e.g., a 4 1/16″ 10M flow cross), a first connector (24) that is shown engaged with a first pump in line (26) (e.g., a 2″ 15M pump in line), and a top connector (28), that is usable for engagement with a blowout preventer, a chemical stimulation apparatus, and/or other apparatuses for performing well intervention operations (not shown). The first pump in line (26) is shown including two barrier valves (30A, 30B), and an emergency quick disconnect connector (32) (e.g., a 2″ EQD connector) usable for engagement with a chemical stimulation unit, a tree running tool, and/or with other devices for performing intervention operations (not shown). The emergency quick disconnect connector (32) can be used for rapid disengagement from the system (10) when it is desirable to quickly isolate the system (10) and/or to move an apparatus or vehicle away from the system (10).

The lower section (16) is shown having a lower connector assembly that includes a second flow cross member (34), having a second connector (36) that is shown engaged with a second pump in line (38), and a bottom connector (40), usable for engagement with a running tool, a wellbore conduit, or similar conduits and/or apparatuses (not shown). The second pump in line (38) is shown having two barrier valves (42A, 42B), and an emergency quick disconnect connector (44), usable for engagement with a chemical stimulation unit and/or to perform other intervention operations (not shown). The emergency quick disconnect connector (44) can also be used for rapid disengagement from the system (10) when it is desirable to quickly isolate the system (10) and/or move an apparatus or vehicle away from the system (10).

In use, a first operating and/or intervention apparatus and/or a chemical stimulation device can be engaged with the upper section (14) of the central conduit (12), above the flow control devices (18, 20), e.g., via the first flow cross member (22) and/or the top connector (28), while a second operating and/or intervention apparatus can be engaged with the lower section (16), e.g., via the second flow cross member (34). For example, a blowout preventer can be engaged to the top connector (28) while a chemical stimulation unit is engaged to the emergency quick disconnect connector (32) of the first pump in line (26), while a running tool is engaged to the bottom connector (40) and an additional chemical stimulation unit or other intervention apparatus is engaged to the emergency quick disconnect connector (44) of the second pump in line (38).

Chemical stimulation, and/or other intervention operations, can be performed through the flow control devices (18, 20) via the first flow cross member (22) (e.g., via the first pump in line (26) or first connector (24) and/or the top connector (28)). Additionally (e.g., simultaneously, sequentially, or alternatively), other intervention operations can be performed independent of the state of the flow control devices (18, 20) via engagement to the lower section (16) via the second flow cross member (34) (e.g., through the bottom connector (40) and/or the second connector (36) or second pump in line (38)). Further, the open bore extending throughout the depicted system (10) (e.g., from the top connector (28) through the flow control devices (18, 20) to the bottom connector (40)) enables wireline operations and similar interventions to be performed independent of other operations performed using the first and second connectors (24, 36) and/or associated pump in lines. As such, the depicted system (10) could be used to enable rapid performance of wireline operations to remove and/or actuate one or more plugs (e.g, through the top connector (28) and central bore of the system (10)), immediately prior to performing chemical stimulation operations through the first and/or second connectors (24, 36, respectively), without requiring substantial reconfiguration, removal, and/or replacement of components.

During use, the upper section (14) can be isolated from the lower section (16) and/or the wellbore below using the flow control devices (18, 20), and from the environment external to the system (10) via the barrier valves (30A, 30B) or similar devices. The lower section (16) can be isolated from the upper section (14) using the flow control devices (18, 20), and from the environment external to the system (10) using the flow control devices (18, 20) and/or the barrier valves (42A, 42B) or similar flow control devices.

Referring now to FIG. 2, a diagrammatic side view of an embodiment of a system (46), usable within the scope of the present disclosure, is shown. The depicted system (46) includes an upper flow cross member (48) having a side connector (50) adapted for engagement with pump in lines and/or intervention apparatuses, a top connector (52) similarly adapted for engagement with lines and/or apparatuses, and a central bore (54) for accommodating fluid flow and/or passage of apparatuses and conduits (e.g., wireline). The system (46) is shown having a lower flow cross member (56), having a side connector (58) adapted for engagement with pump in lines and/or intervention apparatuses, and a bottom connector (60) adapted for engagement with a wellbore conduit, a running tool, or other similar apparatuses. The lower flow cross member (56) includes a central bore (62) in communication with the bottom connector (60) (e.g., for communication with wellbore tubing and/or casing), and a secondary bore (64) in communication with the side connector (58) (e.g., for communication with a wellbore annulus).

A conduit (66) is positioned between the upper and lower flow connectors (48, 56), the conduit (66) having a bore (68) that aligns with the bores (54, 62) of the flow connectors (48, 56) to form a continuous bore extending through the system (46), that can be accessible through the top connector (52), the bottom connector (60), and the side connector (50) of the upper flow cross member (48). Positioned within the conduit are four flow control devices (70A, 70B, 70C, 70D), which are depicted as hydraulic valves, each having a movable member with a throughbore (72A, 72B, 72C, 72D) extending therethrough. When in an open position, the throughbores (72A, 72B, 72C, 72D) are moved into alignment with the bore (68) of the conduit (66), while when in a closed position, the throughbores (72A, 72B, 72C, 72D) are moved out of alignment with the bore (68), such that the body of the valves blocks the flow of fluid through the bore (68). Each of the depicted flow control devices (70A, 70B, 70C, 70D) can be actuatable (e.g., in a linear direction) using corresponding actuators (74A, 74B, 74C, 74D), which can be powered by, e.g., a hydraulic supply (76) that communicates fluid through a control umbilical (78) or similar hydraulic conduit via a lower junction plate (80). Fluid can similarly be communicated through other junction plates, e.g., a middle junction plate (82) and an upper junction plate (84), to actuate additional components (86A, 86B), such as a blowout preventer and/or hydraulic connectors for securing thereto. The depicted system (46) is shown including independent hydraulic access points (90A, 90B, 90C) that can be independently accessed (e.g., by a remotely operable vehicle) to individually actuate and/or access the actuators (74A, 74B, 74C, 74D) or other components (86A, 86B). To provide a contingency for an uncontrolled scenario, a shear pin (88) can be provided to enable immediate disconnection of the hydraulic supply (76) from the system (46).

The depicted system (46) is thereby usable to perform chemical stimulation and/or other intervention operations through the top connector (52) or the side connector (50) of the upper flow cross member (48) to access the wellbore conduit, and through the side connector (58) of the lower flow cross member (56) to access the annulus. Due to the continuous inner bore extending through the system (46), wireline operations and/or the passage of tools and apparatuses therethrough are also possible, simultaneously with or sequentially following other operations performed via the side connectors (50, 58). Hydraulic access points (90A, 90B, 90C) can be usable to access the actuators (74A, 74B, 74C, 74D) and components (86A, 86B), as described previously.

Referring now to FIG. 3, a diagrammatic side view of an embodiment of a system (47), usable within the scope of the present disclosure, is shown. The depicted system (47) is substantially similar to that shown in FIG. 2, having flow cross members (48, 56) disposed on opposing ends of a conduit (66) having flow control devices (70A, 70B, 70C, 70D) therein, which can be actuated by actuators (74A, 74B, 74C, 74D). The actuators (74A, 74B, 74C, 74D) and associated wellbore components (86A, 86B) can be powered using hydraulic supply (76) via a control umbilical (78), which can flow hydraulic fluid via junction plates (80, 82, 84). The depicted system (47) is shown having a plurality of accumulators (92) in communication therewith, and further in communication with a series of vents (96). The accumulators (92) can be recharged via a hydraulic access point (94), and can be used to actuate a flexible jumper via an access point (98). In an emergent situation and/or in various other contingencies, the accumulators (92) can be used to actuate the flow control devices (70A, 70B, 70C, 70D), and/or to actuate or disconnect other system components.

Referring now to FIG. 4, a diagrammatic side view of an embodiment of a system (100) usable within the scope of the present disclosure is shown. The depicted system (100) is substantially similar to that shown in FIG. 3, having flow cross members (48, 56) disposed on opposing ends of a conduit (66) having flow control devices (70A, 70B) therein, which can be actuated by actuators (74A, 74B). The actuators (74A, 74B) and associated wellbore components (86A, 86B) can be powered using a hydraulic supply via a control umbilical (78), which can flow hydraulic fluid via conduits that engage quick disconnect plates (102, 104), which can be separated (e.g., via a shear pin) during an uncontrolled scenario. The depicted system (100) is shown having a plurality of accumulators (92) in communication therewith, which can be used to actuate the actuators (74A, 74B) and/or other components. An intervention tool (106) (e.g., a subsea tree or similar apparatus) is shown engaged with the lower flow cross member (56) for communicating with the secondary bore (64) therein. While the actuators (74A, 74B), wellbore components (86A, 86B), and/or the intervention tool (106) can be actuated using the control umbilical (78), or if necessary, the accumulators (92) FIG. 4 also depicts a plurality of access points (108), through which one or more of the actuators (74A, 74B), wellbore components (86A, 86B), or the intervention tool (106) can be operated, and through which the accumulators (92) can be recharged, such as through use of a Remotely Operable Vehicle or similar means. The access points (108) are shown associated with various combinations of switches, vents, and/or valves.

Embodiments usable within the scope of the present disclosure thereby provide systems and methods that enable both well stimulation operations and other intervention operations to be conducted, simultaneously or sequentially, without requiring removal and/or replacement of equipment, while enabling portions of the system or the entire system to be isolated as needed. Additionally, embodiments usable within the scope of the present disclosure can be operated riglessly and/or using a minimum of equipment, eliminating the need for time consuming use of rigs, risers, and other conventional equipment and conduits.

While various embodiments usable within the scope of the present disclosure have been described with emphasis, it should be understood that within the scope of the appended claims, the present invention can be practiced other than as specifically described herein. 

What is claimed is:
 1. A system for performing operations on a well, the system comprising: a conduit having an upper section and a lower section; a first flow control device positioned between the upper section and the lower section; a second flow control device positioned beneath the first flow control device and between the upper section and the lower section; an upper connector assembly engaged with the upper section, wherein the upper connector assembly comprises: a first flow cross member in fluid communication with the first flow control device; a first connector adapted for connection to a chemical stimulation device; and a top connector adapted for engaging a blowout preventer, for performing well intervention operations therethrough, or combinations thereof; and a lower connector assembly engaged with the lower section, wherein the lower connector assembly comprises: a second flow cross member in fluid communication with the second flow control device; a second connector adapted for connection to a chemical stimulation device; and a bottom connector adapted for engaging a running tool, a wellbore conduit, a blowout preventer, or combinations thereof.
 2. The system of claim 1, wherein the first connector, the second connector, or combinations thereof, comprise an emergency quick disconnect connector.
 3. The system of claim 1, wherein the first flow control device, the second flow control device, or combinations thereof, comprise a ball valve, a hydraulic valve, or combinations thereof.
 4. The system of claim 1, further comprising a first pump in line engaged with the first flow cross member, a second pump in line engaged with the second flow cross member, or combinations thereof.
 5. The system of claim 1, wherein the first flow cross member comprises a first primary bore and a first additional bore fluidly connected with the first primary bore, wherein the second flow cross member comprises a second primary bore and a second additional bore, wherein the second additional bore is fluidly isolated from the second primary bore.
 6. A method for performing operations on a well, the method comprising the steps of: providing a conduit in communication with a well, wherein the conduit comprises at least two flow control devices; engaging a first operating apparatus and a chemical stimulation device with an upper section of the conduit, above said at least two flow control devices; engaging a second operating apparatus with a lower section of the conduit below said at least two flow control devices; performing at least a first operation through the conduit and said at least two flow control devices using the first operating apparatus, the chemical stimulation device, or combinations thereof without requiring removal of the first operating apparatus, the chemical stimulation device, or combinations thereof; isolating the first section from the second section using said at least two flow control devices; and performing a second operation through the conduit using the second operating apparatus.
 7. The method of claim 6, wherein the first operating apparatus comprises a blowout preventer, a well intervention apparatus, or combinations thereof.
 8. The method of claim 6, wherein the second operating apparatus comprises a blowout preventer, a chemical stimulation device, a wellbore conduit, a running tool, a well intervention apparatus, or combinations thereof.
 9. The method of claim 6, wherein the step of engaging the first apparatus, the step of engaging the second apparatus, or combinations thereof, comprises engaging an emergency quick disconnect feature of the top section, the bottom section, or combinations thereof.
 10. The method of claim 10, further comprising disengaging from the emergency quick disconnect feature in a limited quantity of time and transporting the first operating apparatus, the chemical stimulation device, the second operating apparatus, or combinations thereof, away from the conduit.
 11. The method of claim 6, wherein the step of performing the first operation, the step of performing the second operation, or combinations thereof, comprises performing the first operation, the second operation, or combinations thereof riglessly.
 12. The method of claim 11, wherein the step of performing the first operation, the step of performing the second operation, or combinations thereof, comprises the first operation, the second operation, or combinations thereof using a multi service vessel in combination with a hoisting apparatus.
 13. A system for performing operations on a well, the system comprising: a conduit having an upper section and a lower section; a first flow control device positioned between the upper section and the lower section; a second flow control device positioned beneath the first control device and between the upper section and the lower section; and an upper connector assembly engaged with the upper section, wherein the upper connector assembly comprises: a first flow cross member in fluid communication with the first flow control device, wherein the first flow cross member enables fluid flow in at least two directions; a first connector connected to a chemical stimulation device; and a top connector connected to a blowout preventer, a well intervention apparatus, or combinations thereof, wherein the upper connector assembly enables simultaneous or combined operations performed using the chemical stimulation device, the blowout preventer, the well intervention apparatus, or combinations thereof.
 14. The system of claim 13, further comprising: a lower connector assembly engaged with the lower section, wherein the lower connector assembly comprises: a second flow cross member in fluid communication with the second flow control device, wherein the second flow cross member enables fluid flow in at least two directions; a second connector adapted for connection to a chemical stimulation device; and a bottom connector adapted for engaging a running tool, a wellbore conduit, a blowout preventer, or combinations thereof.
 15. The system of claim 14, wherein the first connector, the second connector, or combinations thereof, comprise an emergency quick disconnect connector.
 16. The system of claim 13, wherein the first flow control device, the second flow control device, or combinations thereof, comprise a ball valve, a hydraulic valve, or combinations thereof.
 17. The system of claim 14, further comprising a first pump in line engaged with the first flow cross member, a second pump in line engaged with the second flow cross member, or combinations thereof.
 18. The system of claim 13, wherein the first flow cross member comprises a first primary bore and a first additional bore fluidly connected with the first primary bore, wherein the second flow cross member comprises a second primary bore and a second additional bore, wherein the second additional bore is fluidly isolated from the second primary bore.
 19. A system for performing operations on a well, the system comprising: a conduit having an upper section and a lower section and a bore extending therethrough; at least one flow control device positioned between the upper section and the lower section, wherein said at least one flow control device is operable to open and close the bore; a first flow cross member in fluid communication with the upper section and having a first primary bore extending therethrough in communication with the bore of the conduit, wherein the first flow cross member comprises at least two connectors each adapted for connection to a chemical stimulation device, a blowout preventer, a well tree tool, a well intervention apparatus, or combinations thereof; and a second flow cross member in fluid communication with the lower section and having a second primary bore extending therethrough in communication with the bore of the conduit, wherein the second flow cross member comprises at least two connectors each adapted for connection to a chemical stimulation device, a running tool, a well tree tool, a well intervention apparatus, or combinations thereof.
 20. The system of claim 19, wherein the first flow cross member further comprises a first additional bore fluidly connected with the first primary bore, wherein the second flow cross member further comprises a second additional bore extending therethrough, wherein the second additional bore is fluidly isolated from the second primary bore. 